EP3555414B1 - Système et procédé d'opérations de puits de forage sous-marin en mer - Google Patents

Système et procédé d'opérations de puits de forage sous-marin en mer Download PDF

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Publication number
EP3555414B1
EP3555414B1 EP17822049.7A EP17822049A EP3555414B1 EP 3555414 B1 EP3555414 B1 EP 3555414B1 EP 17822049 A EP17822049 A EP 17822049A EP 3555414 B1 EP3555414 B1 EP 3555414B1
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EP
European Patent Office
Prior art keywords
frame section
riser
lower frame
vertical
firing line
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
EP17822049.7A
Other languages
German (de)
English (en)
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EP3555414A1 (fr
Inventor
Diederick Bernardus Wijning
Joop Roodenburg
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Huisman Equipment BV
Original Assignee
Itrec BV
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Filing date
Publication date
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Publication of EP3555414A1 publication Critical patent/EP3555414A1/fr
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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/002—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling
    • E21B19/004—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling supporting a riser from a drilling or production platform
    • E21B19/006—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables specially adapted for underwater drilling supporting a riser from a drilling or production platform including heave compensators
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B15/00—Supports for the drilling machine, e.g. derricks or masts
    • E21B15/02—Supports for the drilling machine, e.g. derricks or masts specially adapted for underwater drilling
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/08—Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods
    • E21B19/09—Apparatus for feeding the rods or cables; Apparatus for increasing or decreasing the pressure on the drilling tool; Apparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/14—Racks, ramps, troughs or bins, for holding the lengths of rod singly or connected; Handling between storage place and borehole
    • E21B19/146—Carousel systems, i.e. rotating rack systems
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/22—Handling reeled pipe or rod units, e.g. flexible drilling pipes

Definitions

  • the present invention relates to the field of offshore wellbore activities, e.g. drilling a wellbore, completion of a wellbore, wellbore intervention or servicing, and/or other activities that relate to a subsea wellbore.
  • coiled tubing equipment including a coiled tubing injector and/or wireline equipment including a wireline lubricator.
  • operations are performed that involve the use of a so-called riser tension frame, sometimes with one of said coiled tubing injector or wireline lubricator installed in the tension frame.
  • the frame is adapted to attach to the top end of a riser in the firing line.
  • a riser tension frame is suspended from a heave motion compensated hoisting device so as to keep the riser tensioned while the offshore vessel is subjected to heave motion. This can e.g. be done with a fixed length tension frame.
  • riser tension frames have an integrated heave motion compensator assembly, e.g. the structure of the frame including heave motion cylinders as part of the structure of the tension frame, e.g. vertical structural legs of the frame including such cylinders.
  • this integrated motion compensator assembly is normally locked, so non-operative, making the riser tension frame act like a fixed length frame.
  • the integrated motion compensator assembly is then merely provided as a back-up for the heave motion compensated hoisting device from which the tension frame is suspended in heave motion compensating mode.
  • Another operation common in this field is running of a tubulars string, e.g. in well completion wherein a production tubulars string is run into a subsea wellbore, wherein one or more control lines are fitted to the outside of the tubulars string. Oil and/or gas produced by the well are conveyed to the wellhead by this production tubulars string.
  • the completion of a well using production tubing, but also some other operations running some kind of tubular string requires the installation of control lines for electrically, hydraulically and/or optically linking various downhole devices to the wellhead and/or the surface. Control lines may be used to receive data from downhole instruments, e.g. to monitor, regulate and stimulate the flow of the fluids through the production tubing string, e.g.
  • Control and signal lines may carry electric signals, electrical power, hydraulic signals and/or power, optic signals, pneumatic signals and/or power, etc. It is common practice to use clamps to secure these lines at intervals, e.g. at the location of threaded connectors connecting one tubular to another, to the tubulars string. Commonly this is done manually by an operator standing at a level below a slip device from which the tubulars string is suspended in the firing line.
  • the present invention aims to provide measures that form an improvement over existing offshore subsea wellbore activities systems, e.g. with respect to versatility, efficiency, reliability, use of deck and/or other storage space for equipment, etc.
  • the invention provides an offshore subsea wellbore activities system comprising:
  • This system is very versatile and efficient as the wellbore activities device allows for switching between coiled tubing operation and wireline operation, which is frequently desired in the field.
  • the system allows to use the motion arm assembly in the process of handling for example an elongated wellbore tool that has to be fitted at the leading end of the coiled tubing that is to be deployed.
  • Such wellbore tools are often called bottomhole assembly or BHA, and may include one or more of a downhole motor, sensitive electronics, perforator equipment, packers, valves, etc.
  • the inventive system allows to reliably handle such a relatively expensive and fragile tool by means of the motion arm assembly in order to bring the tool in the firing line.
  • the motion arm assembly can be used to stab the tool into the riser, e.g. at least in part, and/or the tool is then suspended from a winch cable that extends vertically in the firing line for vertical handling of the tool in the firing line.
  • the system of the invention may also include one or more of the features discussed in the subclaims and/or in the description of the figures and/or discussed with reference to another aspect of the disclosure.
  • system further comprises:
  • the vertical riser load bearing structure is formed by exactly three vertical riser load bearing struts connecting said lower frame section to said upper frame section in a triangular arrangement, including one rear strut arranged at a rear side of the tension frame facing the tower and two front struts at a front side of the tension frame.
  • the lower frame section is releasably secured to said vertical riser load bearing structure, e.g. to said struts, and the lower frame section comprises a platform adapted to stand on a rig floor in an operative position over the well center.
  • the lower frame section supports, above a platform thereof, at least one of said coiled tubing injector, said wireline lubricator, and said one or more pressure control devices associated with said coiled tubing injector and/or said wireline lubricator.
  • the lower frame section is releasably secured to the vertical riser load bearing structure, and the lower frame section comprises a platform provided with downward projecting support legs protruding beneath the platform and adapted to stand on a rig floor in an operative position over the well center, wherein said platform is at an elevated position above the rig floor.
  • system further comprises a slip device adapted to support a tubulars string suspended from said slip device, wherein the lower frame section is adapted to receive and retain said slip device.
  • the lower frame section is releasably connected to the vertical riser load bearing structure of the tension frame.
  • the lower frame section comprises a platform wherein centrally a riser top connector is arranged that is to be aligned with the firing line.
  • the lower frame section e.g. the platform thereof, is provided with a CT storage stand to store thereon a coiled tubing (CT) pressure control device and with a WL storage stand to store thereon a wireline (WL) pressure control device, e.g. wherein said CT storage stand and said WL storage stand are arranged on diametrically opposed location relative to a central riser top connector.
  • CT coiled tubing
  • WL wireline
  • the lower frame section has a platform whereon horizontal rails are provided.
  • the lower frame section e.g. a platform thereof, is provided with CT pressure control device carrier that travels over rails and is adapted to carry and displace the CT pressure control device from a CT storage stand to the firing line for connection to the riser top connector and vice versa.
  • CT pressure control device carrier that travels over rails and is adapted to carry and displace the CT pressure control device from a CT storage stand to the firing line for connection to the riser top connector and vice versa.
  • the lower frame section e.g. a platform thereof, is provided with WL pressure control device carrier that travels over rails and is adapted to carry and displace the WL pressure control device from the WL storage stand to the firing line for connection to a riser top connector and vice versa.
  • vertical riser load bearing struts e.g. exactly three in a triangular arrangement, connect the lower frame section to the upper frame section.
  • connecting struts are each connected at an upper end thereof via a releasable connection, e.g. via a removable connector pin, to the upper frame section.
  • connecting struts are each connected at a lower end thereof via a releasable connection, e.g. via a removable connector pin, to said lower frame section.
  • the upper and/or lower frame section each comprises sockets that are each adapted to receive therein a spigot end of a strut, wherein for each releasable connection a transverse connector pin is provided that extends through aligned apertures in the socket and the spigot end of the strut.
  • the lower frame section is releasably secured to the vertical load bearing structure, e.g. said struts, and the lower frame section comprises a platform adapted to stand on a rig floor in an operative position over the well center, possibly provided with downward projecting support legs protruding beneath the platform so that said platform stands at an elevated position above the rig floor.
  • the lower frame section is provided with a mobile arm structure having one or more mobile arms, e.g. pivotally connected to the lower frame section, and the mobile arm structure is provided with one or more rail engagement members, e.g. rollers sets, adapted to engage on one or more of said vertical rails, e.g. on trolley rails.
  • a mobile arm structure having one or more mobile arms, e.g. pivotally connected to the lower frame section
  • the mobile arm structure is provided with one or more rail engagement members, e.g. rollers sets, adapted to engage on one or more of said vertical rails, e.g. on trolley rails.
  • the system comprises:
  • the system comprises:
  • the system comprises:
  • the disclosure also relates to an offshore subsea wellbore activities system comprising:
  • the motion arm assembly when fitted with the tubular gripper member, can also be employed to handle tubulars stored in the storage rack.
  • the motion arm assembly can be operated as a piperacker during a drilling operation wherein no use is made of the riser tension frame.
  • the tubular gripper member is employed to handle a wellbore tool to be transferred between the firing line within the riser tension frame and the outside of said frame, e.g. said wellbore tool being stored in the storage rack.
  • the wellbore tool may have a section, e.g. releasably insertable between components or modules of the wellbore tool, dedicated to be gripped by the tubular gripper member.
  • the disclosure also relates to an offshore subsea wellbore activities system comprising:
  • the riser tension frame is provided with exactly three vertical riser load bearing struts connecting said lower frame section to said upper frame section in a triangular arrangement, seen in horizontal cross-section, including one rear strut arranged at a rear side of the tension frame facing the tower and two front struts at a front side of the tension frame.
  • This arrangement provides on the one hand a very stable structure of the tension frame, e.g. compared to known frames having exactly two struts which results in a more or less planar framework, e.g.
  • the frame has to carry both the coiled tubing injector and the wireline lubricator as well as one or more pressure control devices associated with the coiled tubing injector and/or the wireline lubricator (e.g. two complete BOP ram stacks).
  • one or more pressure control devices associated with the coiled tubing injector and/or the wireline lubricator e.g. two complete BOP ram stacks.
  • the invention also relates to a method for performing a wellbore activity wherein use is made of the system according to the invention, e.g. for performing an offshore wireline operation wherein use is made of a system to move a wellbore tool into the firing line, which tool is to be connected to the wireline.
  • the method may include a coiled tubing operation and the motion arm of the system is used to move a coiled tubing tool into the firing line. For example a tool is brought from a position outside the riser tension frame to a position within the tension frame and aligned with the firing line as well as above the wireline lubricator by means of the motion arm assembly.
  • the motion arm assembly is used to transfer an elongated wellbore tool or a wellbore tubular in vertical orientation thereof by means of the motion arm assembly in a substantially lateral motion between a remote position outside of the riser tension frame and an operative position within the riser tension frame and aligned with the firing line via the lateral firing line access passage.
  • a second aspect of the disclosure relates to an offshore subsea wellbore activities system comprising:
  • This system of the second aspect of the disclosure allows for the multi-functionality of the lower frame section of the riser tension frame, at least including this lower frame section playing its role as structural load bearing part of the tension frame and including the lower frame section being detached from the remainder of the riser tension frame and standing on the rig floor in operative position over the well center.
  • this equipment can readily be used when the lower frame section stand, detached from the rest of the frame, on the rig floor.
  • the lower frame section then is used for coiled tubing and/or wireline operations.
  • a slip device is placed on, or even integrated with, the lower frame section, as to allow the lower section to keep a tubulars string suspended from the slip device in the firing line.
  • the second aspect of the disclosure also relates to an offshore subsea wellbore activities system comprising:
  • the second aspect of the disclosure also relates to an offshore subsea wellbore activities system comprising:
  • a mobile arm structure allows to use this arm structure as part of the guidance of the tension frame relative to the tower when the frame is operated in heave compensating mode.
  • the mobile arm structure In stored position of the lower frame section or of the entire tension frame the mobile arm structure can be brought into a retracted or collapsed mode wherein the arm structure takes up little space.
  • the one or more vertical rails on which the mobile arm structure engages extend so low that even when the lower frame structure is placed on the rig floor the arm structure can be brought into proper engagement with said one or more vertical rails.
  • This e.g. allows the arm structure to act as a stabilizer for the lower frame structure that is standing on the rig floor, e.g. absorbing - at least in part - forces in the horizontal plane acting on the lower frame section in the course of operations being performed.
  • the arm structure may act to properly position the lower frame section relative to the firing line when standing on the rig floor, e.g. to achieve alignment with the firing line and thus with a top drive device that may travel up and down above the lower section.
  • the second aspect of the disclosure also relates to a riser tension frame for use in offshore subsea wellbore activities aboard an offshore vessel having a hull subjected to heave motion, wherein the riser tension frame comprises:
  • the second aspect of the disclosure also relates to an offshore subsea wellbore activities system comprising:
  • a third aspect of the disclosure relates to a riser tension frame for use in offshore subsea wellbore activities aboard an offshore vessel having a hull subjected to heave motion, wherein the riser tension frame comprises:
  • the third aspect of the disclosure also relates to a method for onboard assembly of a riser tension frame for use in offshore subsea wellbore activities aboard an offshore vessel having a hull subjected to heave motion, wherein the riser tension frame comprises:
  • the riser tension frame of the third aspect of the disclosure allows for assembly and disassembly, e.g. in view of storage when not in use. Also one can envisage lengthening of shortening of the frame depending on the planned operations to be performed by exchanging one length of struts for another length of struts.
  • the struts, when disassembled, can e.g. be stored horizontally.
  • the lower frame section is also embodied for use when detached from the tension frame, e.g. standing on the rig floor over the well center or even supported on heave motion compensator cylinders that extend underneath the lower frame section (e.g. between the lower frame section and the rig floor). When the lower section is used as stand-alone component it is desirable to allow for storage of the remainder of the tension frame in disassembled state so as to reduce storage spaced requirements.
  • the struts when disassembled, as stored horizontally belowdecks in a storage hold within the hull, e.g. within a hold that is also used for horizontal storage of riser sections or stands.
  • the riser tension frame is preferably embodied with the struts being fixed length monolithic steel struts, e.g. of rectangular cross section.
  • One or more of the struts may be, possibly permanently, fitted with walkways and/or stairs to allow personnel to have access to, for example, one or more of a coiled tubing injector, wireline lubricator, wellbore tool position within the frame (e.g. in the firing line), or other components, etc. in the tension frame.
  • a fourth aspect of the disclosure relates to an offshore subsea wellbore activities system comprising:
  • the frame section is provided with a riser attachment device adapted to attach a riser to said frame section so as to extend in a firing line.
  • the frame section comprises a platform wherein centrally a riser top connector is arranged that is to be aligned with the firing line.
  • the frame section is provided with a coiled tubing injector and associated pressure control device and/or with a wireline lubricator and associated pressure control device.
  • the frame section placed on top of a group of heave motion compensation cylinders is provided with a mobile arm structure having one or more mobile arms, e.g. pivotally connected to the frame section, wherein said mobile arm structure is provided with one or more rail engagement members, e.g. rollers sets, adapted to engage on one or more of said vertical rails on the tower.
  • a mobile arm structure having one or more mobile arms, e.g. pivotally connected to the frame section, wherein said mobile arm structure is provided with one or more rail engagement members, e.g. rollers sets, adapted to engage on one or more of said vertical rails on the tower.
  • the frame section placed on top of a group of heave motion compensation cylinders comprises a platform, which platform is provided with a CT storage stand to store thereon a coiled tubing (CT) pressure control device and with a WL storage stand to store therein a wireline (WL) pressure control device, wherein said CT storage stand and said WL storage stand are arranged on diametrically opposed locations relative to a central riser top connector, and wherein the platform is provided with CT pressure control device carrier that travels over rails and is adapted to carry and displace the CT pressure control device from the CT storage stand to the firing line for connection to the riser top connector and vice versa, and wherein the platform is provided with WL pressure control device carrier that travels over rails and is adapted to carry and displace the WL pressure control device from the WL storage stand to the firing line for connection to the riser top connector and vice versa.
  • CT coiled tubing
  • WL wireline
  • a coiled tubing injector is fitted on top of the coiled tubing pressure control device as a unit, wherein the carrier is adapted to move said unit between the parked position and the operative position in the firing line.
  • the frame section placed on top of a group of heave motion compensation cylinders is provided with a separate carrier for a coiled tubing injector, allowing to move the coiled tubing injector separate from an associated pressure control device.
  • the frame section placed on top of a group of heave motion compensation cylinders is provided with a separate carrier for a wireline lubricator, allowing to move the wireline lubricator separate from an associated pressure control device.
  • an intermediate horizontal frame member is fitted in the structure of the frame section at a level above the one or more pressure control devices, with one or more carriers being provided on said intermediate horizontal frame member to perform transfer of a coiled tubing injector and/or of a wireline lubricator, each between a respective parked position and a firing line position.
  • an additional carrier may include a lifting mechanism adapted to lift and lower the carried injector and/or lubricator relative to the associated pressure control device in view of making and breaking the connection.
  • the frame section comprises a platform and wherein a surface flow tree that may be arranged in a top region of a riser is mounted below the platform.
  • the fourth aspect of the disclosure also relates to a method for performing wellbore activities wherein use is made of the system comprising a frame section that is placed on top of a group of heave motion compensation cylinders, e.g. on four of such cylinders, configured to allow the frame section to perform a heave compensating motion in an associated range of travel along the tower.
  • the present invention also relates to a riser tension frame as discussed herein for use in wellbore activities on a heave motion subjected vessel and to such use thereof.
  • the present invention also relates to methods wherein use is made of a system and/or riser tension frame and/or lower riser frame section and/or frame section supported on top of a group of heave motion compensation cylinders as described herein.
  • Figure 1 shows a part of the hull 1 of an offshore vessel, here with a moonpool 2 through which imaginary firing line 3 extends to the subsea site of a wellbore or wellhead or other subsea equipment.
  • an offshore vessel is adapted for performing offshore drilling and/or other wellbore related activities, e.g. well completion, well intervention, etc.
  • Figure 1 shows a tower 10 that is here embodied as a mast with a closed contoured steel structure with the firing line 3 outside of the mast itself.
  • the mast 10 is arranged adjacent the moonpool.
  • the tower 1 could be a derrick over the moonpool, so that the firing line 3 extends within the framework of the derrick.
  • Other arrangement e.g. with the mast 10 arranged over an elongated moonpool to form two moonpool areas, e.g. front and aft of the mast 10, are equally known and possible.
  • Figure 1 shows a rig floor 4 and a well center 5.
  • one or more slip devices can be arranged at or near the well center.
  • Figure 30 shows two such slip devices 6a, b in a sunken compartment below the surface of the rig floor.
  • the slip devices 6a, b are movable, e.g. skiddable between opposed parking positions remote from the firing line and an operative position aligned with the firing line 3.
  • a slip device 6a, b can retain a suspended tubular string, e.g. during drilling operations, including tripping in and out of the wellbore.
  • the mast 1 is at the side of the well center 5 provided with two parallel vertical trolley rails 7, 8.
  • a trolley 20 is guided along the trolley rails 7,8.
  • a top drive device 30 is attached to the trolley 20.
  • the top drive device 30 comprises in this example four electric top drive motors 31 which commonly drive, via gearbox or transmission in housing 32, a rotary stem or quill 33.
  • the quill 33 is connectable, e.g. via a threaded connection, e.g. via a saver sub, to the top end of a tubular aligned with the firing line.
  • the top drive device 30 is able to impart rotary motion and drive torque to a tubulars string.
  • a main firing line hoisting device 50 is provided and is adapted to move the trolley 20 with the top drive device 30 up and down along the vertical trolley rails 7,8.
  • the hoisting device 50 comprises a crown block 51, a travelling block 52, and a hoisting cable arranged in a multiple fall arrangement between said blocks 51, 52.
  • the travelling block 52 here is fitted to the frame of the trolley 20.
  • One or more winches of the hoisting device e.g. arranged within or underneath the mast 10, operate the hoisting cable. These one or more winches may be heave compensated winches as is known in the art and/or one or more other heave compensation devices may be arranged to act on the cable, e.g. on the cable stretch between the one or more winches and the crown block 51 as is known in the art. This allows to move the travelling block 52, and thus the trolley 20, in a heave compensating mode.
  • a left-hand motion arm rail 60 and a right-hand motion arm rail 61 are present on opposed lateral sides of a vertical path of travel of the trolley 20 with the top drive device 30 along said the vertical trolley rails 7,8.
  • motion arm assembly 70, 71, 72, 80, 81, 82 is arranged on each of said motion arm rails 60, 61.
  • Each assembly is, as preferred independently controlled from any other motion arm assembly on the same rail 60, 61, vertically mobile along the respective rail by a respective motion arm assembly vertical drive.
  • assemblies 70, 71, 72, 80, 81, 82 have an identical structure.
  • the assembly 71 has a base 74 that is mounted vertically mobile on the vertical rail 60.
  • the assembly 71 further comprises an extensible and retractable motion arm 75, here a telescopic arm with a first arm section 75a connected to the base 74, and one or more, here two, telescopic second and third arm sections 75b, 75c.
  • the arm sections are extensible by associated hydraulic cylinders of the arm 75.
  • the motion arm has an operative reach that encompasses the firing line 3 so that the arm can handle drilling tubulars and/or well center equipment, or other tooling that needs to be presented or held in the firing line.
  • the arm 75 here the first arm section 75a, is connected to the base 74 via a slew bearing 76 allowing to rotate the arm about a vertical axis by means of an associated slew drive.
  • the assembly 70 further comprises a motion arm assembly vertical drive, e.g. with one or more motors 78 each driving a pinion meshing with a rack that extends along the rail 60.
  • a motion arm assembly vertical drive e.g. with one or more motors 78 each driving a pinion meshing with a rack that extends along the rail 60.
  • the base 74 can move along the at least one vertical motion arm rail 60 and, for example, the drive with motor 78 is sufficiently strong to do so while the motion arm assembly carries a load in the firing line 3 of at least 1000 kg, preferably at least 5000 kg.
  • the motion arm assembly 70 is able to support at least one of a well center tool, e.g. an iron roughneck tool 85, or a tubular gripper member 90, and allowing to bring said well center tool or tubular gripper member in the firing line.
  • a well center tool e.g. an iron roughneck tool 85, or a tubular gripper member 90
  • each of said tubular gripper members 90 and/or the iron roughneck tool 85 is provided with a mechanical coupler part that is adapted to be mated with the mechanical coupler part that is fitted on the motion arm 75 such that the respective gripper member, iron roughneck tool, or other well center tool, becomes fixed to the respective motion arm and fully and directly follows any motion of the motion arm.
  • tubulars storage rack 110, 120 here embodied as carrousels as is known in the art, adapted to store therein multi-joint tubular stands, e.g. triples, quads, or even stands of six joints, in vertical orientation therein.
  • the tubular stands can comprises drill pipe, casing, etc.
  • a multi-joint tubular can be gripped by said assemblies in unison and then transferred between a storage rack 110, 120 on the one hand and a position over the well center 5 in the firing line 3.
  • the motion arm assembly is, as is preferred, usable as part of a piperacker.
  • the one or more motion arm assemblies 70, 71, 72, 80, 81, 82 e.g. at least one, is provided with a motion arm assembly vertical drive that forms part of a heave motion synchronization system, e.g. an electronic control unit that controls the vertical drive motor 78.
  • this synchronization system is adapted to bring a motion arm assembly and any object carried thereby, e.g. a wellbore tool or a tubular retrieved from a storage rack, into a vertical motion that is synchronous with the heave compensation motion of a still to be described riser tension frame or lower frame section thereof.
  • This synchronization capability of the motion arm assembly with the heave motion for example allows the transfer of such wellbore tool or tubular between a position outside of the riser tension frame and a position within the riser tension frame and aligned with the firing line.
  • a motion arm assembly preferably provided with said synchronization functionality, is provided with a man-riding basket or cage, e.g. allowing transfer of personnel to the riser tension frame while performing heave motion compensation motions relative to the tower 10.
  • the riser tension frame can be equipped with a boarding station, e.g. with a safety door or other barrier, governing the transfer between the man-riding cage or basket and the riser tension frame.
  • FIG. 1 show, as part of a wellbore activities device, a riser tension frame 200 that is to be suspended along the front side of the mast 10 by means of the hoisting device 50 and the trolley 20 in a manner that allows, as is known for riser tension frames, to perform a heave compensation of the frame 200.
  • the frame 200 is a fixed length frame, so lacking internal heave compensation cylinders.
  • the winch or winches of the hoisting device 50 are of the active heave compensation type and/or one or more heave compensation devices act on the cable from which the travelling block 51 is suspended.
  • a heave compensator device could be arranged between the fixed length frame and the trolley.
  • the frame 200 is not suspended from the trolley 20 but from the top drive device 30, e.g. from bails connected to a part of the top drive device 30.
  • the latter design is not preferred due to the need to have the top drive device 30 in place when operating the riser tension frame 200 and the strains placed on the top drive device 30 requiring a heavy design thereof.
  • riser tension frame 200 comprises:
  • the wellbore activities device further comprises:
  • each of the coiled tubing injector 300 and the wireline lubricator 400 is received by and individually movable within the riser tension frame 200 between a parking position remote from the firing line 3 and an operative position aligned with the firing line 3 allowing to use a selected one of said coiled tubing injector and said wireline lubricator for performing a coiled tubing operation or a wireline operation respectively when aligned with the firing line.
  • the wellbore activities device here the tension frame 200 plus preferably the CT injector 400, WL lubricator 300, and associated pressure control devices 320, 420 and any other components installed in or on said frame 200, such as walkways, provides a lateral firing line access passage 280 (depicted with dashed line in figure 8 , 10 ; figure 12 illustrates the upper and lower borders 290a,b of passage 280) having a height of at least 40ft., e.g. of 50 ft., and a width of at least 1 ft.
  • the passage 280 is dimensioned to allow for the transfer of objects having a greater cross-sectional dimension than a relatively slender wellbore tool or wellbore tubular.
  • the passage 280 has a lower zone that is dimensioned to allow for access to the firing line 3 of a roughneck device held on the arm of a motion arm assembly, e.g. to assist in making or breaking of threaded connections, possibly with a tubular also being held in the firing line by an arm of a higher located arm assembly.
  • the passage 280 is wide over its entire height, e.g. 3 ft. or more, instead of being wide in a lower zone and narrow in an upper zone.
  • a motion arm assembly on the tower 10 is used to handle one or more of the:
  • a motion arm assembly is used to transfer such a component into and/or out of the frame 200, possibly with said frame 200 then being arranged out of alignment with the firing line in order to facilitate access to the component by means of the motion arm assembly as such transfer does not necessitate proper alignment with the firing line.
  • the lower frame section 250 is releasably secured to the vertical riser load bearing structure, here to the struts, and the lower frame section comprises a platform 251 adapted to stand on a rig floor 4 in an operative position over the well center 5.
  • the lower frame section 250 supports, above the platform 251, the coiled tubing injector 300, the wireline lubricator 400, and the associated pressure control devices 320,420.
  • the versatility of the removable lower frame section 250 is further depicted in figure 29 , where the lower frame section 250 comprises platform 251 with downward projecting support legs 252 protruding beneath the platform and standing on a rig floor 4 in an operative position over the well center, wherein platform 251 is at an elevated position above the rig floor.
  • the lower frame section 250 here has been cleared of the coiled tubing injector 300, the wireline lubricator 400, and the associated pressure control devices 320,420.
  • a slip device 6c is arranged which is adapted to support a tubulars string suspended from the slip device 6c. For example the height between the platform 250 and an underlying floor.
  • the rig floor or a temporary floor located at a level lower than the rig floor is such that a person can stand underneath the platform, so a height of at least 2 meters.
  • This arrangement may be advantageous when running a tubular string to which one or more control or signal lines 285 are to be secured externally by said person, e.g. by means of clamps that are fitted at intervals on the tubular string, e.g. at every threaded connector between joined tubulars.
  • the lower frame section 250 may comprise attachment members for one or more sheaves or other conductors of such control or signals lines, e.g. said lines coming from remotely located spools, e.g. arranged in a separate carrier on the rig floor remote from the well center.
  • the versatility of the removable lower frame section 250 is further depicted in figure 30 , where the lower frame section 250 is placed on top of a group of heave motion compensation cylinders 295, e.g. on four of such cylinders to perform heave compensating motion in an associated range of travel along the tower 10.
  • This may e.g. be done with the lower frame section merely being provided with the mentioned slip device 6c, but one can also envisage such a use wherein the lower frame section is provided with either a coiled tubing injector 300 and associated pressure control device 320 and/or with a wireline lubricator 400 and associated pressure control device 420.
  • the lower frame section 250 has platform 251 wherein centrally a riser top connector 255 is arranged that is to be aligned with the firing line 3 in operations.
  • the riser top connector here means a connector for coiled tubing and/or wireline equipment to the top end of the riser 270.
  • a surface flow tree 271 may be arranged in the top region of the riser 270, below the platform 251.
  • the connector 255 is a HydraConn connector as is known in the art.
  • the platform is provided with a CT storage stand 256 to store thereon a coiled tubing (CT) pressure control device 320 and with a WL storage stand 257 to store therein a wireline (WL) pressure control device 420.
  • CT storage stand 256 and WL storage stand 257 are arranged on diametrically opposed location relative to central riser top connector 255.
  • the stand 256 and/or stand 257 is provided with a connector, e.g. a HydraConn connector, similar to connector 255.
  • rails 258 are provided on said platform 251, here as preferred a pair of rails extending from left to right and along the front and the rear of the region where one can exchangeably fit the connector 255 or the slip device 6c.
  • the platform is provided with CT pressure control device carrier 260 that travels over said rails 258 and is adapted to carry and displace the CT pressure control device 320 from the CT storage stand 256 to the firing line 3 for connection to the riser top connector 255 and vice versa. Also the platform is provided with WL pressure control device carrier 265 that travels over rails 258 and is adapted to carry and displace the WL pressure control device 420 from the WL storage stand 257 to the firing line 3 for connection to the riser top connector 255 and vice versa.
  • the coiled tubing injector 300 is fitted on top of the coiled tubing pressure control device 320 and is moved by the carrier 260 as a unit between the parked position and the operative position in the firing line.
  • a separate carrier is provided for the injector 300, allowing to move the injector separate from the associated pressure control device 320.
  • the same may be done for the wireline lubricator 400 and its associated pressure control device 420.
  • an intermediate horizontal frame member is fitted in the structure of the frame 200 at a level above the pressure control devices 320, 420, with one or more carriers being provided on said intermediate horizontal frame member to perform transfer of the injector 300 and/or lubricator 400 between a parked position and a firing line position.
  • such an additional carrier may include a lifting mechanism adapted to lift and lower the carried injector 300 and/or lubricator 400 relative to the associated pressure control device 320, 420 in view of making and breaking the connection.
  • the carriers 260, 265 here each include a lifting mechanism, here including one or more hydraulic jacks 266, 267, allowing to controllably raise and lower the respective component or unit of components, e.g. to obtain release from the storage stand and to mate with the connector 255 and vice versa.
  • a lifting mechanism here including one or more hydraulic jacks 266, 267, allowing to controllably raise and lower the respective component or unit of components, e.g. to obtain release from the storage stand and to mate with the connector 255 and vice versa.
  • the vertical riser load bearing struts 230, 231, 232, connecting the lower frame section 250 to the upper frame section 210 are releasable at both ends.
  • struts 230, 231, 232 are each connected at an upper end thereof via a releasable connection, e.g. via a removable connector pin 235, 236, 237 to upper frame section 210.
  • the struts 230, 231, 232 are each connected at a lower end thereof via a releasable connection, e.g. via a removable connector pin, 241, 242, 243 to lower frame section 250.
  • the upper and lower frame section 210, 250 each comprises sockets 250a,b,c that are each adapted to receive therein a lower spigot end of a strut. And for each releasable connection a transverse connector pin 235, 236, 237, 241, 242, 243 is provided that extends through aligned apertures in the socket and the spigot end of the strut.
  • riser tension frame 200 is possible if the vessel is equipped with a proper crane, which is common for such vessels. For example one could proceed position the lower frame section 250 on deck within reach of a crane, then raise the vertical riser load bearing struts 230, 231, 232 by the crane and placed them vertically with their spigot ends in the sockets of the lower frame section 250 and then secure them therein by means of said transverse connector pins.
  • the upper frame section 210 is placed on the vertically arranged struts 230, 231, 232 by means of the crane so that the top spigot ends of the struts are received in the corresponding sockets of the upper frame section 210 and then secured therein by means of transverse connector pins.
  • a removable pin type connection is proposed between the lower frame section 250 and the remainder of the riser tension frame 250, which may be done irrespective of the presence of struts or an alternative vertical load bearing construction.
  • the pins are driven by an associated actuator, e.g. hydraulic jack, mounted on the lower frame section to facilitate the release and engagement of these connector pins.
  • the lower frame section 250 is releasably secured to vertical load bearing structure, e.g. to struts 230,231,232, and that the lower frame section comprises a platform 251 adapted to stand on a rig floor 4 in an operative position over the well center, possibly provided with downward projecting support legs 252 protruding beneath the platform so that said platform stands at an elevated position above the rig floor.
  • the lower frame section 250 is provided with a mobile arm structure 285 having one or more mobile arms 286, here pivotally connected about a horizontal pivot axis to the rear side of the lower frame section 250.
  • the mobile arm structure is provided with one or more rail engagement members, here two rollers sets 287, 288, each adapted to engage on a respective vertical rails, here each on a respective vertical trolley rails 7, 8.
  • the frame section 250 preferably comprises one or more actuators 289, e.g. hydraulic jacks, to perform the motion of the mobile arm structure 285.
  • the rail or rails onto which the arm structure 285 engages extends so low towards or even onto the level of the rig floor 4 that that when the lower frame structure stands on the rig floor the rail engagement members, here roller sets 287, 288, can be brought into engagement with the respective rail.
  • This allows to use to arm structure as both a positioner for the frame section (to guarantee alignment with the firing line) and as a stabilizer, e.g. absorbing horizontal forces acting on the frame section 250 during various operations.
  • the depicted system also comprises a pair of parallel skid rails 15 provided on rig floor 4 and extending along opposed sides of the well center 5. It is envisaged that a skid pallet 16, see figure 2 , is provided and adapted to be skidded over skid rails 15 provided on the rig floor 4.
  • the lower frame section 250 is adapted to be releasably secured to this skid pallet 16 so as to allow skidding of the complete riser tension frame 200 or of just the lower frame section 250, e.g.
  • FIG. 2 also depicts part of the driller's cabin 500, which overlooks the area of the well center 5 on the rig floor 4 as well as the front face of the tower 10 and thus the riser tension frame 200 when suspended along the front of the tower 10.
  • Figure 2 as well as figure 29 , also show part of a catwalk machine 550 which is present to handle tubulars as is known in the art.
  • riser tension frame 200 is directly suspended from the trolley 20, so that the vertical riser load is not transferred through any part of the top drive device 50.
  • each of the tensile links 21, 22 has an eyelet at the lower end thereof and the tension frame top section has opposed hooks 211, 212 that can be mated with an eyelet of the link 21,22, here a left-hand and right-hand hook 211, 212.
  • the riser tension frame 200 and the trolley 20 have a spigot and socket connection arrangement 25, se figure 25 , here at the location of the top end of a rear strut 232, so as to obtain a positioning and stabilizing of the frame 200 relative to the trolley by said spigot and socket connection.
  • a single spigot and socket connection is provided in combination with two tensile links 21, 22 connecting to the top frame section at other locations to arrive at a triangular arrangement of connections between the trolley and the top section 210.
  • the trolley 20 has a vertical central rear frame member 26 on which the top drive device 30 is vertically guided, e.g. allowing to lower the top drive device 30 down along the member 26 when removing the top drive 30 from the trolley 20.
  • the rear frame member 26 of the trolley 20 lines up with the rear strut 232 of the frame 200 and interconnects therewith directly, e.g. via the mentioned connection 26 or another connection.
  • top drive device 30 is supported by the trolley 20 in a manner that allows for vertical mobility of the device 30, e.g. in view of making or breaking a tubular connection, e.g. a threaded connection.
  • a top drive vertical motion actuator 37 is provided between the top drive 30 and the trolley 20.
  • a wrench device 70 may be provided on the trolley 20 to assist in this process.
  • the riser tension frame 200 has a vertical firing line access passage 202 all the way from the top section 210 to the lower frame section 250, in particular extending through the top section in the firing line 3. This allows for the use of the top drive 30, e.g. of the mud swivel commonly associated with the top drive 30, or of an independent mud swivel 38, in operations using the tension frame 200.
  • the top frame section 250 is provided with a mobile top sheave 252 that is displaceable between a firing line position where a cable or wire can be passed from the top sheave along the firing line and a retracted or parked position (see 252b in figure 7 ) wherein the firing line 3 and thus the passage 202 is cleared.

Claims (13)

  1. Système d'activités de puits de forage sous-marins au large comprenant :
    - un navire de haute mer ayant une coque soumise à un mouvement de tangage, ledit navire étant équipé :
    - d'une tour (10),
    - d'un centre de puits (5) dans lequel s'étend une ligne de tir (3),
    - d'un dispositif de levage à compensation de tangage (50), qui offre un mode de compensation de tangage,
    - d'un rail de bras de déplacement vertical (60, 61) le long de ladite tour (10),
    - d'un ensemble de bras de déplacement (70, 71, 72, 80, 81, 82) comprenant une base et un bras de déplacement extensible et rétractible (75), dans lequel la base est guidée par ledit au moins un rail de bras de déplacement vertical (60, 61),
    - un entraînement vertical d'ensemble de bras de déplacement (76) qui est adapté pour déplacer la base du bras de déplacement le long dudit rail de bras de déplacement vertical (60, 61) par rapport à la tour,
    - d'un dispositif d'activités de puits de forage comprenant un châssis de tension de colonne montante (200), dans lequel ledit châssis de tension de colonne montante comprend :
    - une section de châssis supérieure (210) adaptée pour être suspendue ou suspendue audit dispositif de levage à compensation de tangage,
    - une section de châssis inférieure (250) munie d'un dispositif de fixation de colonne montante adapté pour fixer une colonne montante sur ladite section de châssis inférieure de façon à s'étendre dans la ligne de tir,
    - une structure portante de colonne montante verticale, formée par exemple d'entretoises (230, 231, 232), qui relie ladite section de châssis inférieure (250) à ladite section de châssis supérieure (210),
    dans lequel ledit dispositif d'activités de puits de forage comprend en outre :
    - un injecteur de tubage en spirale (300),
    - un lubrificateur de câble (400),
    - un ou plusieurs dispositif(s) de régulation de pression (320, 420) associé(s) audit injecteur de tubage en spirale et/ou audit lubrificateur de câble,
    dans lequel chacun dudit injecteur de tubage en spirale (300) et dudit lubrificateur de tubage (400) est reçu par et individuellement mobile dans ledit châssis de tension de colonne montante (200) entre une position de stationnement distante de ladite ligne de tir (3) et une position de fonctionnement alignée avec ladite ligne de tir (3) afin de pouvoir utiliser l'un dudit injecteur de tubage en spirale et dudit lubrificateur de câble pour effectuer une opération de tubage en spirale ou une opération de câble, respectivement, en cas d'alignement avec la ligne de tir,
    et dans lequel le dispositif d'activités de puits de forage offre un passage latéral d'accès à la ligne de tir (270) qui possède une hauteur d'au moins 40ft. (12,2 m) et une largeur d'au moins 1 ft. (0,35 m) afin de pouvoir transférer un outil de puits de forage allongé (150) ou un matériel tubulaire de puits de forage à la verticale de celui-ci à l'aide de l'ensemble de bras de déplacement (70, 71, 72, 80, 81, 82) avec un mouvement sensiblement latéral entre une position distante à l'extérieur du châssis de tension de colonne montante et une position de fonctionnement dans le châssis de tension de colonne montante, et alignée avec la ligne de tir (3).
  2. Système selon la revendication 1, dans lequel le système comprend en outre :
    - au moins un rack de stockage de tubulaires (110, 120) adjacent à la tour (10) et adapté pour stocker des tubulaires, de préférence des tubulaires à joints multiples, à la verticale,
    - un élément de préhension de tubulaires (90) adapté pour être prévu sur ou prévu sur ledit bras de déplacement (71) et pour saisir un tubulaire, de sorte que ledit tubulaire puisse être déplacé à l'aide dudit bras de déplacement entre le rack de stockage et ladite ligne de tir.
  3. Système selon la revendication 1 ou 2, dans lequel ladite structure portante de colonne montante verticale est formée exactement par trois entretoises portantes de colonnes montantes verticales (230, 231, 232) qui relient ladite section de châssis inférieure à ladite section de châssis supérieure selon un agencement triangulaire, comprenant une entretoise arrière (232) prévue au niveau d'un côté arrière du châssis de tension qui fait face à la tour (10) et deux entretoises avant (230, 231) au niveau d'un côté avant du châssis de tension.
  4. Système selon l'une quelconque des revendications 1 à 3, dans lequel ladite section de châssis inférieure (250) est fixée de manière amovible sur ladite structure portante de colonne montante verticale, comme sur lesdites entretoises, et dans lequel ladite section de châssis inférieure comprend une plate-forme adaptée pour reposer sur un plancher de forage (4) dans une position de fonctionnement par-dessus le centre du puits (5),
    et dans lequel ladite section de châssis inférieure supporte, au-dessus de la plate-forme de travail (251), au moins l'un dudit injecteur de tubage en spirale (300), dudit lubrificateur de câble (400), et dudit ou desdits dispositif(s) de régulation de pression (320, 420) associé(s) audit injecteur de tubage en spirale et/ou audit lubrificateur de câble.
  5. Système selon l'une quelconque des revendications 1 à 4, dans lequel ladite section de châssis inférieure (250) est fixée de manière amovible sur ladite structure portante de colonne montante verticale, et dans lequel ladite section de châssis inférieure comprend une plate-forme (251) équipée de montants de support qui se projettent vers le bas (252) et qui dépassent sous la plate-forme, et adaptés pour reposer sur un plancher de forage (4) dans une position de fonctionnement par-dessus le centre du puits, dans lequel ladite plate-forme (251) se trouve dans une position élevée au-dessus du plancher de forage,
    et dans lequel ledit système comprend en outre un dispositif antidérapant (6c) adapté pour supporter un groupe de tubulaires suspendu audit dispositif antidérapant,
    et dans lequel la plate-forme de la section de châssis inférieure est adaptée pour recevoir et retenir ledit dispositif antidérapant (6c).
  6. Système selon l'une quelconque des revendications 1 à 5, dans lequel, éventuellement, ladite section de châssis inférieure (250) est reliée de manière amovible à ladite structure portante de colonne montante verticale du châssis de tension,
    et dans lequel ladite section de châssis inférieure comprend une plate-forme (251), dans lequel un raccord supérieur de colonne montante (255) est prévu de manière centrale et aligné avec la ligne de tir (3),
    et dans lequel la plate-forme est équipée d'un support de stockage CT (256) configuré pour stocker un dispositif de régulation de pression (320) de tubages en spirale (CT), et d'un support de stockage WL (257) configuré pour stocker un dispositif de régulation de pression (420) de ligne de tir (WL), dans lequel ledit support de stockage CT (256) et ledit support de stockage WT (257) sont prévus à des emplacements diamétralement opposés par rapport audit raccord supérieur de colonne montante centrale (255),
    dans lequel des rails (258) sont prévus sur ladite plate-forme (251),
    et dans lequel la plate-forme est équipée d'un support de dispositif de régulation de pression de CT (260) qui est adapté pour se déplacer sur lesdits rails (258) et est adapté pour acheminer et déplacer le dispositif de régulation de pression de CT (420) entre le support de stockage de CT et la ligne de tir en vue du raccordement au raccord supérieur de colonne montante (255) et inversement, et dans lequel la plate-forme est équipée d'un support de dispositif de régulation de pression de WL (265) qui est adapté pour se déplacer sur lesdits rails (258) et est adapté pour acheminer et déplacer le dispositif de régulation de pression de WT (420) entre le support de stockage de WT et la ligne de tir en vue du raccordement au raccord supérieur de colonne montante (255) et inversement.
  7. Système selon l'une quelconque des revendications 1 à 6, dans lequel les entretoises portantes d colonne montante verticale relient ladite section de châssis inférieure à ladite section de châssis supérieure,
    et dans lequel lesdites entretoises (230, 231, 232) sont chacune reliées, au niveau d'une extrémité supérieure de celles-ci via un raccord amovible, comme une broche de raccord amovible (235, 236, 237), à ladite section de châssis supérieure (210),
    et dans lequel lesdites entretoises (230, 231, 232) sont chacune reliées, au niveau d'une extrémité inférieure de celles-ci, via un raccord amovible, comme une broche de raccord amovible (241, 242, 243), à ladite section de châssis inférieure (250),
    dans lequel, par exemple, lesdites sections de châssis supérieure et inférieure (210, 250) comprennent chacune des fiches (250a, b, c) qui sont chacune adaptées pour recevoir un embout mâle d'une entretoise, dans lequel, pour chaque raccord amovible, une broche de raccord transversale (235, 236, 237, 241, 242, 243) est prévue et s'étend dans des ouvertures alignées au sein de la fiche et de l'embout mâle de l'entretoise.
  8. Système selon l'une quelconque des revendications 1 à 7, dans lequel la section de châssis inférieure (250) est fixée de manière amovible sur ladite structure portante verticale, comme lesdites entretoises, et dans lequel ladite section de châssis inférieure comprend une plate-forme (251) adaptée pour reposer sur un plancher de forage (4) dans une position de fonctionnement au-dessus du centre du puits, et est éventuellement équipée de montants de support qui se projettent vers le bas (252) et qui dépassent sous la plate-forme de sorte que ladite plate-forme se trouve dans une position élevée au-dessus du plancher de forage,
    et dans lequel la section de châssis inférieure (250) est équipée d'une structure de bras mobile (285) qui possède un ou plusieurs bras mobile(s) (286), relié(s) par exemple de manière pivotante à la section de châssis inférieure, et dans lequel ladite structure de bras mobile est équipée d'un ou plusieurs élément(s) d'engagement de rails, comme des groupes de galets (287, 288), adaptés pour s'engager sur un ou plusieurs desdits rails verticaux (7, 8), comme des rails de chariot.
  9. Système selon l'une quelconque des revendications 1 à 8, dans lequel le système comprend :
    - une paire de rails à longerons parallèles (15) montés sur un plancher de forage (4) et qui s'étendent le long des côtés opposés du centre du puits (5),
    - un châssis mobile à longerons (16) adapté pour être déplacée sur ladite paire de rails à longerons parallèles (15) prévus sur le plancher de forage, dans lequel ladite section de châssis inférieure (250) est adaptée pour être fixée de manière amovible sur ledit châssis mobile à longerons (16) de façon à permettre le déplacement du châssis de tension de colonne montante entier (200) ou de la section de châssis inférieure (250) avec ledit au moins l'un dudit injecteur de tubage en spirale (300), dudit lubrificateur de câble (400), et dudit ou desdits dispositif(s) de régulation de pression (320, 420) associé(s) audit injecteur de tubage en spirale et/ou audit lubrificateur de câble supporté dessus, d'un emplacement de stockage distant vers un emplacement dans la ligne de tir.
  10. Système selon l'une quelconque des revendications 1 à 9, dans lequel le système comprend :
    - un ou plusieurs rail(s) de chariot vertical/verticaux (7, 8) le long de la tour (10),
    - un chariot (20) suspendu au dispositif de levage (50) et mobile le long dudit ou desdits rail(s) de chariot vertical/verticaux,
    - un dispositif d'entraînement supérieur (30) supporté par le chariot (20),
    dans lequel le châssis de tension de colonne montante (200) est directement suspendu au chariot (20), la charge de la colonne montante verticale n'étant transférée par aucune partie du dispositif d'entraînement supérieur, le chariot (20) étant par exemple équipé d'une paire de liaisons de traction mobiles (21, 22) qui dépendent du chariot et sont reliées ou peuvent être reliées à la section de châssis supérieure (210) du châssis de tension de colonne montante (200), les liaisons de traction (21, 22) ayant par exemple chacune un œillet au niveau de l'extrémité inférieure de celles-ci, et la section supérieure du châssis de tension ayant des crochets opposés (211, 212) qui peuvent être accouplés avec un œillet (21, 22), comme un crochet de gauche et de droite (211, 212).
  11. Système selon l'une quelconque des revendications 1 à 10, dans lequel le système comprend :
    - un ou plusieurs rail(s) de chariot vertical/verticaux (7, 8) le long de la tour (10),
    - un chariot (20) suspendu au dispositif de levage (50) et mobile le long dudit ou desdits rail(s) de chariot vertical/verticaux,
    - un dispositif d'entraînement supérieur (30) supporté par le chariot (20),
    dans lequel le châssis de tension de colonne montante (200) est directement suspendu au chariot (20), la charge de la colonne montante verticale n"étant transférée par aucune partie du dispositif d'entraînement supérieur,
    et dans lequel le châssis de tension de colonne montante et le chariot possèdent un système de raccord à embout mâle et à fiche, par exemple à l'emplacement de l'extrémité supérieure d'une entretoise arrière (232), de façon à obtenir un positionnement et une stabilisation du châssis (200) par rapport au chariot à l'aide dudit système d'embout mâle et de fiche.
  12. Procédé d'exécution d'activités de puits de forage dans lequel un système selon une ou plusieurs des revendications précédentes est utilisé.
  13. Procédé selon la revendication 12, dans lequel l'ensemble de bras de déplacement est utilisé pour transférer un outil de puits de forage allongé (150) ou un tubulaire de puits de forage à la verticale à l'aide de l'ensemble de bras de déplacement (71) avec un mouvement sensiblement latéral entre une position distante à l'extérieur du châssis (200) de tension de colonne montante et une position de fonctionnement dans le châssis de tension de colonne montante, et alignée avec la ligne de tir (3), via le passage d'accès latéral à la ligne de tir (270).
EP17822049.7A 2016-12-16 2017-12-14 Système et procédé d'opérations de puits de forage sous-marin en mer Active EP3555414B1 (fr)

Applications Claiming Priority (2)

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EP3555414A1 (fr) 2019-10-23
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US11053753B2 (en) 2021-07-06
US20200011141A1 (en) 2020-01-09

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